Well completion system and method, drilled well exploitation method, use of same in the exploitation/extraction of drilled wells, packaging capsule, telescopic joint, valve and insulation method, and valve actuation system, selection valve and use of same, connector and electrohydraulic expansion joint

ABSTRACT

The present invention describes a completion system for drilled wells having valves mechanisms, drives, sensors and devices able to promote an exploration of wells, safer, more efficient and, therefore, more economically viable. Specifically, the present invention comprises a system allowing the installation of smart completion in single or multiple producing zones, comprising valves mechanisms, drives, sensors, between other devices disclosed by the present invention. The present invention is in the fields of petroleum engineering and mechanic engineering.

FIELD OF THE INVENTION

The present invention refers to an exploration system of drilled wellsand a method for extracting fluids from the said drilled wells. Thepresent invention is in the fields of petroleum engineering, andmechanic engineering.

BACKGROUND OF THE INVENTION

Oil prospecting has been the subject of long studies and majortechnological contributions in recent decades, despite the emergence ofnew sources of energy use, the prognostics point out many decades aheadof great importance of this type of natural resource.

The smart completion of oil producing wells is a type of completion thatallows producing several producing zones together, monitoring andcontrolling the said producing zones remotely and individually. The useof smart completion enables exploration of marginal reserves andacceleration of hydrocarbon production through joint and controlledproduction of reservoirs, significantly increasing the recovery factorof the field.

Common oil producing wells, or having smart completion, need at somepoint, mechanisms to supplement the loss of natural pressure of rocksbearing hydrocarbons. The methods are quite varied, but the gas-lift andSubmerged Centrifugal Pumping (BCS) are usually preferred when the wellsare submarine and/or with high flow. Depending on the oil viscosity,either of these two methods makes a choice. For high viscosities andhigh flow rates, BCS is invariably the chosen lifting method.

For proper monitoring of the pressures and temperatures of smartcompletions in oil reservoirs, electronic sensors are installed in theproduction column (as deep as possible). Usually this occurs below thecapsule where the BCSs are housed. In this way, it is necessary to passelectric cables and hydraulic lines and/or chemical products, whichconnect the devices to the surface. The most common method of installingthese lines and cables is by attaching them to the production columnswith metal clips on each sleeve of the tubes. The passage through thecapsule, externally, requires a well with larger internal diameters soas to be able to accommodate the capsules with the clamps which willfasten such lines and cables thereto. Often, even with larger welldiameters, this is possible, requiring such components to be passedthrough capsules internal part, resulting in other more constructivelycomplex problems.

Normally, to perform electric cables and hydraulic lines passage insidethe capsule, it is necessary to use connectors and/or joints of wetexpansion electro-hydraulic connections to interconnect the upper partwith the lower one of the capsule. In addition, it is necessary toadjust the length of the whole submerged electric pump assembly with thecapsule length. That means, as the BCS assembly will have to adjust intwo fixed points inside the capsule, it is necessary to use a wetelectro-hydraulic expansion joint, which the oil market also searchesfor development.

Another major problem faced with conventional compositions, that is,when the submerged electric pump assembly falls joint to the capsules,it is the great probability of objects, which remain in the well,resulting from the production columns, such as metal clamping hooks ofthe power electric cable, to fall inside the well, mainly in horizontalwells and of great slope. In the column drag, when it is removed forpump changes, one or more hooks may break and fall to the bottom of thewell, on the gravel packer. This type of event usually generates theneed for complex special operations, called “fisheries”, difficult tosucceed, with a high risk of well loss. This type of problem is inherentto the BCS lifting method and it is necessary to live with such risk inthe best possible way, betting heavily on the reliability of the hookmaterials.

In addition, the accidental fall of objects in the well is frequent (itis part of the daily operation), but its consequences are disastrous.Whenever this occurs, always accompanied by great uncertainties, thechances of great economic losses in the identification of the fallenobject, called “fish”, and its subsequent removal, are significant.

Another important aspect, which should be mentioned, is that the averageuseful life of BCS is 2 years. That is, in this average time interval, aprobe workover must occur for BCS replacement that has stopped working.This workover lasts an average of 45 days and, in addition to the highexpenses with “probe diaries”, it is necessary to internalize the timethat the well has stopped producing (loss of profit), awaiting probe forworkover. To minimize this, the well is usually equipped with BCS andgas-lift mandrel, which will start as soon as the pump stops working,while the probe does not reach. This time can be long and depends on thedemand for probes in the period demanded.

These mandrels are usually positioned below the capsule where the BCSare housed. This prevents its access with slickline, for valveexchanges, as they are below the pumps. The reason for not beingpositioned above is the possibility of being able to use them also forreverse circulation, “annular×column”, removing the largest possiblevolume of oil from the production column, during workovers for pumpexchange. Due to its positioning in an inaccessible place for slicklineoperation, any problems with the valves can only be solved by removingthe entire column with the BCS assembly. It should be noted thatgas-lift valves operate optimally with large volumes of gas but they arepoorly tolerant under fluid flow scenarios at high flow rates. This isthe main reason for failures when reverse circulation is required to“dampen the well” during a workover, limiting the circulation flow,resulting in large losses of probe times (probes are rented per hour).

In view of the scenario that was exposed, there is a great impasse inthis sector of oil production. While smart completion increases the wellrecovery factor by prolonging the time the well will require workovers,at the cost of expensive and complex equipment, the use of BCSinevitably requires the use of probe workovers in the wells to the pumpchange. This scenario of doubts and uncertainties hinges on oilprospecting companies, how to reconcile the use of more complexequipment to reduce the number of workovers with other equipment thatincrease the number of workovers due to the short lifespan, especiallythe BCS assembly.

Searching for the prior art, the following documents regarding the themewere found:

Document CN103382835 discloses one completion system of multipleproducing zones provided with packers separating the said producingzones in order to provide a segregation between the said producingzones. Each producing zone has one smart control device, for example,the first producing zone is controlled by one first smart controldevice, the second producing zone is controlled by a second smartcontrol device, and so on. The production column is associated to allproducing zones, but it produces fluids only from that zone where thesystem decides to produce. This invention's teachings refer on anautomated system to detect which zones is producing fluids with lessamount of undesired fluids mixed to the fluids of interest. Suchdocument does not suggest how to reconcile the fluids prospection fromwells with smart completion using smart mechanisms of high technology,in order to reduce the costs with the wells; mainly those associated tothe exchange of the submerged centrifugal pumping assembly and theworkovers with probe.

Document U.S. Pat. No. 8,127,845 discloses a completion system ofmultiple producing zones of hydrocarbons based on the selectivesegregation of zones that will produce fluids. Through a sliding sleeve,the operator commanding a rod of service is able to isolate a producingzone misaligning the holes present in the inner capsule of the holespresent in the outer tube, while when it is desired to produce fromanother producing zone, this same operator aligns the said holes suchthat the fluids may move up through the production column. The saidalignment and misalignment of holes is made with the service rod and itsouter recess that, in contact with the inner recess present in thesliding sleeve transmits the axial movement axial of the service rod inorder to align or misalign holes. This document discloses somefacilities in the completions, since it is possible to produce severalproducing zones in a joint or separated manner. For example, if in acertain producing zone the pressure is too higher regarding a secondproducing zone, it is possible to produce from this producing zone ofgreater pressure until pressures are balanced, and the hydrocarbonsformation occurs simultaneously between several producing zones.Further, it is possible to drain undesired fluids (water, mud, etc) of acertain producing zone, while the further ones are closed, avoidingpossible contamination. This document does not disclose a form to reducethe workover time of oil producer wells, mainly those provided withsmart completions. Such document also does not disclose a mean to removethe submerged centrifugal pumping assembly in wells with smartcompletion without the risk of complex and onerous fisheries.

Document US20140083684 discloses a completion system of hydrocarbonsproducing wells that permeate through multiple formation. The system,among several embodiments presented, is based on packers dividingmultiple formation zones and, through a pressure sensor analyzing thepressure in the said formation zone send collected information throughthe cable. The said information is used to control the flow that isformed from each one of the production zones. Conventional equipments ofa completion include gravel, pressure sensor, filtering screen and,mainly, a flow control valve driven by one hydraulic control. The flowcontrol valve is able to totally close the formation zone, or simplyrestrict part of the production flow, according to the moment needs. Thesystem of the present document has also a device for pumping theproduction flow, safety valve and formation total isolating valve. Thesaid document does not disclose how to produce multiple formation zonesreconciling the minimum need of workover with probe, using the submergedcentrifugal pumping equipment, with short lifespan.

Document U.S. Pat. No. 8,651,188 refers a gas lift valve comprisinglongitudinal tubular structure provided with an entry and an output, aflow path between the entry and the output, and one flow tube arrangedinside the tubular structure. Such document has as disadvantage the factof it does not provide a solution for fluids path of different densitiesand by the fact of it does not provide a mean to increase the gas flow.

Document U.S. Pat. No. 8,662,184 discloses a capsule system for coatinga set of two submerged pumps that may operate simultaneously or inbackup system. The said document highlights about the importance ofusing two pumps in a completion due to the difficulties associated tothe said pumps exchange. Besides suggesting that the capsule assemblymust be removed from well coating internal part for maintenance, theinventor did not preview facilities in the removal of the pumps assemblyfrom inside the said capsule, such that time-consuming jobs for suchoperation are necessary.

In addition to the considerable difference to the present invention, thecapsule does not have any facility when removing the pump assembly, afurther point away from the present invention is the fact that the saidcapsule comes out of the oil well to replace the pump assembly, sincethis capsule is joint with the remainder of the assembly.

Document U.S. Pat. No. 7,150,325 has a system of submerged pumpcomprising a primary coating capsule having internally a capsule of mainhousing, an inner pump to this and an outer casing involving the saidprimary coating in order to form an annular space. The primary capsulehas in its lower end a polished hole with a sleeve or flapper typevalve. The primary coating capsule is fixed to the well through itsupper end housing in the primary support. The stamp provideswater-tightness to the upper end fit. The main capsule have sealingstamps and a check valve. BCS assembly is located inside the mainhousing capsule and comprises more specifically, a centrifugal pump,fluids inlet in its lower portion and an engine below the said input.BCS assembly has one adaptor connecting the upper part of thecentrifugal pump to the member and this said member connects to thecapsule support. The member and the adaptor may be one single piece. Thefluid path to outside is made through vertical path and through sidepath. When the BCS assembly replacement is necessary, one ROV open theupper cap, connects a tool to the hole and, through the lifting system,removes the BCS assembly together with the main housing capsule. Anoticeable difference between this document and the present invention isin the fact that BCS assembly is removed together with its coatingcapsule, besides other capsule is internal to the production well, moreweight will be lifted and consequently larger machines are needed, inaddition to not being spared any work, since the pump should bedisassembled from the said capsule. Other noticeable difference in thisdocument is the fact that it does not preview a secondary system forpetroleum lifting, as for example the gas-lift.

Thus, from the literature researched, no documents were found to beanticipating or suggesting the teachings of the present invention, sothat the solution proposed here has novelty and inventive activitycompared to the prior art.

SUMMARY OF THE INVENTION

Thus, the present invention discloses a completion system for drilledwells having valves mechanisms, drives, sensors and devices able topromote an exploration of wells, safer, efficient and, therefore, moreeconomically viable.

In a first object, the present invention discloses a completion systemfor drilled wells comprising:

a. valves mechanisms;

b. drives;

c. sensors;

d. expandable joint for adjusting the distance between systemcomponents;

e. shut-off valve;

f. system for controlling shut-off valve drive;

g. control valve of operation and maintenance;

h. decoupling/expandable electro-hydraulic connector.

In a second object, the present invention discloses an explorationsystem of drilled well comprising lifting means of fluid contained indrilled well, being the said lifting mean a set of submerged centrifugalpump and/or gas lift system, the lifting mean being arranged inside thecapsule (IT) housed in removable manner inside the drilled well.

In a third object, the present invention has an exploration system ofmultiple producing zones in drilled well comprising:

a. at least two extraction regions, being the extraction regionsisolated from each other in the annular region; and

b. lifting assembly (PA) arranged inside the capsule (IT);

being the annular region a perimeter clearance existing between thelifting assembly (PA) and the inner wall of the capsule (IT).

In a forth object, the present invention has a method of extraction indrilled well having exploration system of multiple producing zones wherethe said system is provided with locators feed-thru (6) with packer sealbore (11) and elastomer for sealing.

In a fifth object, the present invention discloses a capsule forconditioning components of exploration system of drilled well comprisinga hollow inner region and a housing outer region inside the drilledwells, the said capsule being able of:

a. housing the lifting and control components of fluid extractingcontained in the drilled well; and

b. allowing the simultaneous mounting and removal of the said liftingand control components of extracting inside the well.

In a sixth aspect, the present invention has an exploration method indrilled well with capsule for conditioning components comprising thefollowing steps:

a. inserting a coating capsule (IT) inside a drilled well;

b. inserting a lifting assembly (PA) inside the coating capsule (IT).

In a seventh object, the present invention has a telescopic joint foradjusting the mounting distance between components of an explorationsystem of drilled well comprising linear extension means for connectingcomponents of an lifting assembly (PA) and/or for adjusting the totallength of lifting assembly (PA).

In an eighth object, the present invention claims an isolating valve forexploration system of drilled well comprising opening and closing drivethrough pressure control applied in the annular space (AE).

In a ninth object, the present invention has a method for closing andisolating formations in drilled well comprising at least a step whereina shut-off valve (CV) is controlled by hydraulic means.

In a tenth object, the present invention discloses a system forcontrolling the drive of isolating valve for exploration system ofdrilled well comprising opening and closing drive through:

a. pressure control applied in the annular space (AE); and

b. pressure and/or drag resulting from kinetic energy imposed to highfluid.

In a eleventh object, the present invention brings a selecting valve ofoperation fluid comprising a body of the selecting valve (65) providedwith two passages in order to segregate the flow of a primary fluid ofthe flow of a secondary fluid, being the primary fluid provided with atleast one property different from the secondary fluid.

In a twelfth object, the present invention claims the use of selectingvalve for controlling operation and maintenance of the gas liftequipment where the selecting valve is as defined in this descriptionand is intended to an exploration system of drilled well.

In a thirteenth object, the present invention discloses anelectro-hydraulic (EP) connector for exploration system of drilled wellcomprising:

a. at least one internal assembly (22); and

b. at least one external assembly (23)

wherein:

-   -   the internal assembly (22) is able to couple to the external        assembly (23);    -   the internal assembly (22) has electrical connections (87 and        80) and hydraulic connections (76);    -   the external assembly has electrical connections (87 and 80) and        hydraulic connections (76); and    -   the connections are allocated in order to coincide when the        coupling takes place.

In a fourteenth object, the present invention brings theelectric-hydraulic expansion joint comprising:

a. tubular lower component provided with:

-   -   thread in the lower part for connecting into the        electro-hydraulic connector;    -   sealing in the upper part between the lower component and the        inner cylinder;    -   hexagonal lock system able to prevent the internal column turn        and to allow the torque transmission between the lower and upper        component;    -   lock system for column decline with the extension fixed in the        totally closed position;    -   external ring (upper and lower) for aligning external hydraulic        and electric lines;    -   bars for filling the empty space between external hydraulic and        electric lines; and    -   protection liner of the internal hydraulic and electric lines,

b. tubular upper component provided with:

-   -   cylindrical top (95) with thread in the center for the inner        sliding tube;    -   thread for connection into the production column (96); and    -   peripheral threads (97) for connecting hydraulic and electric        lines.

In a fifteenth object, the present invention has an exploration methodin drilled well using one electro-hydraulic connector and/orelectric-hydraulic joint as defined in this description.

In a sixteenth and last object, the present invention has the use ofexploration/completion system of drilled well, being the system asanyone defined above being intended to hydrocarbons extraction indrilled wells, in special petroleum.

These and other objects of the invention will be immediately valued bythose skilled in the art and by the companies with interests on thesegment, and will be detailed described for its reproduction in thefollowing description.

BRIEF DESCRIPTION OF THE FIGURES

Aiming to better define and clarify the content of the patent presentapplication, the present figures are presented.

FIG. 1 illustrates a first main tube (MT1) for coating the drilledwells. Such first main tube (MT1) has packer seal bore (11) in its lowerportion, in order to promote the control of the said drilled well.

FIG. 2 discloses an embodiment for the first inner capsule (IT1) thatwill be used in a well having a single producing zone (7).

FIG. 3 illustrates a first lifting assembly (PA1) to be used with thefirst inner capsule (IT1) in drilled well having one single producingzone (7).

FIGS. 4.1 and 4.2 illustrate a sequence of removal from the firstlifting assembly (PA1) for wells of a single producing zone (7). Morespecifically, FIG. 4.1 illustrates one well having the first liftingassembly (PA1) inserted into the first inner capsule (IT1), and FIG. 4.2illustrates how is the removal of the first lifting assembly (PA1)without removing the first inner capsule (IT1).

FIG. 5 illustrates an embodiment of the present invention, with a smartcompletion provided with production column (1) with the second innercapsule (IT2) and second lifting assembly (PA2).

FIG. 6A and 6B depict the production column (1) sectioned into two partsfor a better detailing of its inner components.

FIGS. 7, 8 and 9, illustrate, respectively, the second lifting assembly(PA2) decoupled from the second inner capsule (IT2) that, in turn, isdecoupled from the second main tube (MT2).

The sequence of FIGS. 10.1, 10.2 and 10.3 illustrate a step-by-step ofhow the handling tool (10) acts in the inner valve (13), in order toallow the fluids to be produced from the perforation region (14).

FIG. 11 depicts details of the submerged centrifugal pumping assembly,called pumping device (4).

FIG. 12 discloses an embodiment for electro-hydraulic telescopic joint(TJ) used in the production column (1), as the present inventionteachings.

FIGS. 13 and 14 illustrate a comparison of drilled wells havingproduction columns (1) and telescopic joint (TJ). Specifically, FIG. 13illustrates a well wherein the production column is not equipped withtelescopic joint (TJ), and FIG. 14 illustrates a production column (1)provided with the said telescopic joint (TJ).

FIG. 15 discloses an embodiment of the shut-off valve (CV) used in theproduction column (1) to stop the fluids production from a drilled well.

FIG. 16 illustrates operation details of an embodiment of the shut-offvalve (CV) of the present invention.

FIG. 17 illustrates details of how the mechanism acting directly in theshut-off valve (CV) of the present invention operates.

FIG. 18 illustrates an exploded view of the components present In oneembodiment for shut-off valve (CV), as the present invention teachings.

FIG. 19 illustrates an embodiment for the mechanism responsible for thefact that the shut-off valve (CV) moves in one single direction.

FIG. 20 illustrates a side view of the shut-off valve (CV), according tothe present invention.

FIGS. 21.1, 21.2 and 21.3 illustrate the sequence of driving theshut-off valve (CV) associated to a control mechanism (CM).Particularly, FIG. 21.1 illustrates the shut-off valve (CV) in an openposition and with the drilled well producing fluids. The image 21.2illustrates one instant wherein, after the fluids production stop, theinner sleeve (17), by acting a first actuation mean (18), acts thecontrol mechanism (CM). The image 21.3 illustrates one instant wherein,through the pressure inserted in the annular region of the productioncolumn (1), the control mechanism (CM) returns opening the shut-offvalve (CV).

FIGS. 22.1, 22.2 and 22.3 illustrate a second embodiment for theshut-off valve (CV), where the shut-off valve body (46) controls onlythe ducts interconnecting the annular space (AE) to the duct carryingthe produced fluids.

FIG. 22 illustrates one comparison in each driving condition of a valveexecution of smart completion gradually closing of the presentinvention.

FIG. 23 illustrates an embodiment for selective valve (SV) that isinstalled in the first or second capsule (IT1 or IT2), according to thepresent invention teachings. In this image, the selective valve (SV)allows the fluids path through a primary hole (19).

FIG. 24 shows an embodiment for selective valve (SV) of the presentinvention, where the fluids path is being allowed by one secondary hole(20).

FIG. 26 depicts an embodiment of the selective valve (SV) of the presentinvention applied in a production column (1), in order to promote fluidssegregation that enter into the gas lift mandrel (21).

FIG. 26A has the external assembly (23) of the electro-hydraulic (EP)connector in the disconnected position, according to the presentinvention teachings.

FIG. 26B has the internal assembly (22) of the electro-hydraulic (EP)connector of the present invention in the disconnected position.

FIG. 27 has the electro-hydraulic (EP) connector of the presentinvention in the coupling position of the inner (22) and outer (23)assemblies.

FIGS. 28.1 and 28.2 illustrate the sequence for removing the pumpingdevice (4) of drilled wells having production columns (1) andelectro-hydraulic (EP) connector. Specifically, FIG. 28.1 illustratesone drilled well with the coupled electro-hydraulic (EP) connector andpumping device (4) attached to the completion remaining. But FIG. 28.2illustrates the electro-hydraulic (EP) connector disconnection, where itis possible to note how the pumping device (4) removal works.

FIG. 29 illustrates a second embodiment for telescopic joint (TJ) of thepresent invention. This mechanism is able to adapt to variations oflength experienced in the production column (1) by slipping the outertube (24) regarding the inner tube (25). A hexagonal lock (26) ensuresthe torque transmission between outer and inner tubes. This mechanism isfixed to the upper part of the electro-hydraulic (EJ) connector throughthe outer thread (27).

DETAILED DESCRIPTION OF THE INVENTION

The present invention discloses a completion system for drilled wellshaving valves mechanisms, drives, sensors and devices able to promote anexploration of wells, safer, more efficient and, therefore, moreeconomically viable.

It is, therefore, one first object of the present invention to provide acompletion system for drilled wells comprising:

-   -   a. valves mechanisms;    -   b. drives;    -   c. sensors;    -   d. expandable joint for adjusting the distance between system        components;    -   e. shut-off valve;    -   f. system for controlling shut-off valve drive;    -   g. control valve of operation and maintenance;    -   h. decoupling/expandable electro-hydraulic connector.

It is a second object of the present invention to provide an explorationsystem of drilled well comprising lifting means of fluid contained indrilled well, being the said lifting mean a submerged centrifugal pumpassembly and/or gas-lift system, the lifting mean being arranged insidethe capsule (IT) housed in a removable manner inside the drilled well.

It is a third object of the present invention to provide an explorationsystem of multiple producing zones in drilled well comprising:

-   -   a. at least two extraction regions, being the extraction regions        isolated from each other in the annular region; and    -   b. lifting assembly (PA) arranged inside the capsule (IT); being        the annular region in a perimeter clearance existing between the        lifting assembly (PA) and the capsule inner wall (IT).

It is a forth object of the present invention to provide a method ofextraction in drilled well having exploration system of multipleproducing zones where the said system is provided with locatorsfeed-thru (6) with packer seal bore (11) and elastomer for sealing.

The system of smart complementation proposed comprises multipleproducing zones, locators feed-thru (6) with packer seal bore (11) andelastomer for sealing.

The present invention has a smart completion system with at least twoproducing zones, since the separation of the producing intervals insub-zones allows a greater control of each interval and, even producingtogether, it optimizes the hydrocarbons recovery of each zone. This isbecause as Smart Completion valves work by restricting, from fullopening to full closing, each interval, uniformizing as each zone's flowpressures.

The total recovery of hydrocarbons, when producing the intervalstogether, presents economic advantage that significantly overcomes therecovery obtained with the individualized production of each intervaluntil its complete exhaustion. This demonstrates one of the advantagesof using smart completions, in addition to the demonstrated economy withworkovers using the prior art probes, it is also possible to increasethe recovery factor of the oil reservoirs, i.e., higher recovery rateswith lower production costs.

Although the petroleum industry already has various forms of smartcompletion, most of them depend on the application of feed thru packersfor insulation between producing zones, causing each installation pointto have a column squeeze. Electric cables, hydraulic lines and chemicalspath is made inside the solid body of these packers that must providehydraulic seal at the path points. As there is still no consolidatedtechnique of wet electro-hydraulic connectors/disconnectors, the use ofthese completions today is considered infeasible.

The proposed invention, however, allows the use of smart completions ofmultiple zonas without the need of packers feed thru. Instead, suchelements are replaced by locators feed thru, which elastomeric elementsseal polished areas (seal bores) inside the capsule, however, notproviding anchorage. The smart completion recovery is, thus, simples andno element (such as: valves, pressure and temperature sensors, chemicalinjection mandrels) need to be replaced, it its respective tests on thesurface are positive.

The insulation of the producing intervals is performed throughelastomers as the current ones “Swelling Packer” or other similarelements, with the same function. These go down with the capsule andshould not provide anchorage against the coated well.

In an embodiment, the present invention is combined to a system forextracting petroleum comprising at least: i) a coating capsule; ii) asubmerged electric pump assembly; wherein the submerged electric pumpassembly is installed independently inside the coating capsule.

The extraction capsule comprises: internally polished tube, coatingtube, gas lift mandrel housing with selective entry for gas and fluid,formation isolating valve, retention valve, and a sealing anchor withelastomeric elements.

The submerged electric pump assembly comprises: electric cable, pump,electric engine, tubes, and telescopic joint.

Due to system uses an electric pump, it becomes necessary one powerelectric cable to go down coupled with the production column, attachedto the same by clamps, to provide electrical energy for engines movingthe centrifugal pumps.

All this submerged electric pump assembly is inside the coatingwater-tight capsule, isolating the formation produced fluids from therest of the well, called annular space (space formed between theproduction coating and the production column+BCS capsule). The higherthe flow produced, the greater the power required by the engines, whichwill have larger external diameters and the capsules that will housethem will also need to be larger.

In workovers operations for exchanging the submerged electric pumpassemblies, the non-solid capsule remains in the well, allowing anyobject that falls into the well to be easily recovered (since they willbe inside the capsule). This very important aspect prevents such objectsfrom falling above the “gravel packer” which would result in the needfor a special complex and risky “fishing” operation, which could lead tothe loss of the well.

With respect to the stops of the submerged electric pump assemblies fordamage, the option to continue producing the well using gas-lift can beused with the gas injected by the annulus entering the gas-lift mandrelhousing to reach the gas-lift mandrel. The gas-lift mandrel housing candirect the flow into the mandrel or into the column, depending on theflow of pumped fluids. That is, the system of the present invention isselective regarding the pumped flows and the types of fluids: whethergas or liquid. This is critical for preserving high-speed gas-liftvalves generated by fluids pumped into the annular space during damping.

It is a fifth object of the present invention to provide a capsule forconditioning components of the exploration system of drilled wellcomprising a hollow inner region and a housing outer region inside thedrilled wells, the said capsule being able of:

-   -   a. housing lifting and control components for extracting fluid        contained in the drilled well; and    -   b. allowing simultaneous mounting and removal of the said        lifting and control components for extracting from well inside        part.

The proposed system aims to overcome all deficiencies of the currentsystems with joint capsule with significant economic advantage andmitigation of problems risks related to special operations of complex“fisheries”.

The proposed system comprises at least: i) one coating capsule; ii) onesubmerged electric pump assembly; wherein the submerged electric pumpassembly is independently installed inside the coating capsule.

The proposed system, when disentangling the capsule of the submergedelectric pump assembly, results in a greater flexibility in thecompletions with simpler mounts in the surface. Thus, the “non-jointcapsule” is mounted and declined in the well, just after the lowercompletion decline, normally composed of screens of the “gravel pack”system (isolating valve of the formation and “gravel packer”).

The method for extracting petroleum comprises the steps of inserting anon-joint capsule inside the drilled well; and inserting a submergedelectric pump assembly inside the non-joint capsule.

In one embodiment, the extraction capsule comprises: internally polishedtube, coating tube, gas-lift mandrel housing with selective entry forgas and fluid, formation isolating valve, retention valve, and a sealinganchor with elastomeric elements.

In one embodiment, the submerged electric pump assembly comprises:electric cable, pump, electric engine, tubes, and telescopic joint.

It is a sixth object of the present invention to provide an explorationmethod in drilled well with capsule for conditioning componentscomprising the following steps:

a. inserting a coating capsule (IT) inside a drilled well;

b. inserting an lifting assembly (PA) inside the coating capsule (IT).

In one embodiment, the steps of the method occur independently from eachother.

Because the system uses an electric pump, it is necessary the loweringan electric power cable joint to the production column, fastened to thesame by clamps, to provide electrical energy for engines moving thecentrifugal pumps.

All this submerged electric pump assembly is inside the coatingwater-tight capsule, isolating the formation produced fluids from therest of the well, called annular space (space formed between theproduction coating and the production column+BCS capsule). The higherthe flow produced, the greater the power required by the engines, whichwill have larger external diameters and the capsules that will housethem will also need to be larger.

In workovers operations for exchanging the submerged electric pumpassemblies, the non-solid capsule remains in the well, allowing anyobject that falls into the well to be easily recovered (since they willbe inside the capsule). This very important aspect prevents such objectsfrom falling above the “gravel packer” which would result in the needfor a special complex and risky “fishing” operation, which could lead tothe loss of the well.

According to the stops of the submerged electric pump assemblies causedby damage, the option to continue producing the well using gas-lift canbe used with the gas injected by the annulus entering the gas-liftmandrel housing to reach the gas-lift mandrel. The gas-lift mandrelhousing can direct the flow into the mandrel or into the column,depending on the flow of pumped fluids. That is, the system of thepresent invention is selective regarding the pumped flows and the typesof fluids: whether gas or liquid. This is critical for preservinghigh-speed gas-lift valves generated by fluids pumped into the annularspace during damping.

Advantages presented by the present invention comprise: fast assemblyand lowering of the capsules; fast assembly of pumping assemblies;possibility of pump exchanges without the need to remove the capsules;possibility to eliminate maneuvers of balances and dummy run;elimination or minimization of the possibility that “fishes” inside thewell generate complex and risky “fisheries” with great financial lossesand even loss of well; possibility of adding recoverable Mandrel of GasLift (MGL) with the BCS assemblies; possibility to perform TFR with BCSand superior completion only by changing the pumps used in eachoperation without the need to remove the capsule.

It is a seventh object of the present invention to provide a telescopicjoint for adjusting the mounting distance between components of anexploration system of drilled well comprising linear extension means forconnecting components of an lifting assembly (PA) and/or for adjustingthe total length of lifting assembly (PA).

In one embodiment, the telescopic joint comprises means for passing thefunctional devices through the joint; and means for regulating the totallength of the joint.

In one embodiment, functional devices comprise hydraulic lines and/orelectric cables, for remote feeding of components of the systemcomponents of exploration of drilled well.

In one embodiment, functional devices comprise piping of chemicals ableto inject them in predefined regions of the drilled well, to ease thefluid extraction/lifting process.

In one embodiment, the means for length regulation comprise expandablehydraulic units.

In one embodiment, the joint comprises: outer liner (32); upperconcentric sleeve (33); outer flow tube (34); cable (35) for pressureand temperature sensor; expandable hydraulic unit (36); sliding sleeve(37); inner liner (38); inner flow tube (39); lower concentric sleeve(40); driving line (41); and mechanical lock (42).

In one embodiment, the present invention provides a process forextracting petroleum using a telescopic joint as previously defined.

The present invention has the following advantages: enable the use ofsmart completions of multiple zones; reduce welding times in workoversfor exchanging sets of joint BCS with smart completion; and allowcompletions with hydraulic valves remotely controlled.

It is an eighth object of the present invention to provide an isolatingvalve for exploration system of drilled well comprising opening andclosing drive through pressure control applied in the annular space(AE).

The present invention comprises a valve for closing and isolatinghydrocarbons-producer formations, being such valve preferably controlledby hydraulic means.

In one embodiment, the valve for closing and isolating is exclusivelycontrolled by hydraulic means.

In one embodiment, the valve for closing and isolating comprises acylindrical wrap (54), lower connection flange (52), flange holes (55),valve shell (56), shut-off valve body (46), grooved cylindrical shaft(46S), spiral reservoir (53), linear actuator (43) and upper connectionflange (51).

In one embodiment, the valve for closing and isolating comprises in thesame body holes offset 90 degrees such that such holes alternate thevalve opening for production column and the closing for annular space.

In one embodiment, the valve for closing and isolating is arranged abovethe lower completion allowing the reverse circulation for cleaning thecolumn without flow rate limit.

In one embodiment of the present invention, a method for closing andisolating hydrocarbons-producer formations comprises at least one stepwherein a shut-off valve is controlled by hydraulic means.

In a ninth object, the present invention has a method for closing andisolating formations in drilled well comprising at least one stepwherein a shut-off valve (CV) is controlled by hydraulic means.

In one embodiment, the method comprises an additional step of reversecirculation for column cleaning without flow rate limit.

In one embodiment, the method comprises a step of positions switching ofthe shut-off valve between the opening for production column and theclosing for annular space.

The valve of the present invention has several advantages as: allowclosing the well and isolating the formation by hydraulic action in theannular space of the wells; eliminate the control line for its drive andcontrol, making the wellhead equipments project simpler; allow severaloperations of reverse circulations with high flow rates, improvingwells' cleaning; allow performing TFR (Formation test for coated well)with bottom closing; simplify the control mechanism increasing thereliability of it (there is no index system); and allow the variation inthe opening area to the flow.

It is a tenth object of the present invention to provide a system forcontrolling the isolating valve driving for exploration system ofdrilled well comprising opening and closing drive through:

-   -   a. pressure control applied in the annular space (AE); and    -   b. pressure and/or drag resulting from kinetic energy imposed to        high fluid.

In one embodiment, illustrated in FIGS. 21.1, 21.2 and 21.3, the valvepositions are indicated during a flow (FIG. 21.1) during a productionstop (FIG. 21.2) and in the well reopening (FIG. 21.3) wherein itbecomes necessary to annular space pressurization. By doing so, thefluid will take two paths. The first will pressurize acting pistons thatwill decline and rotate the sprockets, joint to the actuator cylinder,through two small racks. Turning the actuator cylinder counter-clockwisewill let the well open. The second path taken by the annular fluid willhave to overcome the opposite effort in the differential piston exertedby the pressure in the column. As the area of the differential piston ismuch larger in the area that acts on the pressure in the column, inorder to obtain the balance of forces, high pressure must be applied tothe opposite side where the annular pressure, whose area is muchsmaller, is applied. By pushing the differential piston, the path willbe closed to the pressures coming from the column and released to thoseapplied in the annular.

Thus, the hydraulic actuator is pushed to the right, closing the path ofthe fluid that was pumped to power the actuator piston, responsible foropening the valve. The pressure will be “mopped” until the hydraulicactuator is again pushed to the left, the drainage hole coinciding withthe access channel to the actuator pistons. When this occurs, all“mopped” pressure will drain into the column and the nitrogen compressedinto the nitrogen spiral reservoir by pushing up the actuator pistonsthat will force the rotation of the gear clockwise closing the well. Itshould be noted that the “trigger” of the bottom closure process is themechanical actuator driven whenever the flow of the well is interrupted.This occurs because when the flow occurs, the upstream×downstreampressure differentials generated in the choke tube can push it upwards,overcoming the force of a spring. At this time, another spring pushesthe mechanical actuator to the right, closing the path for pressuresfrom the column, keeping the hydraulic actuator in its position ofclosing the drainage hole. By interrupting the flow, for any reason, theupstream×downstream pressures acting on the choke tube become equalizedand the spring is able to push the choke tube downwards, which willconsequently force the hydraulic and mechanical actuator assembly to theleft, causing the drainage hole to return to the position coincidingwith the access channel to the actuating pistons which in turn willimmediately release the pressure that had been “mopped” in the spiralnitrogen reservoir.

In an embodiment, the smart completion and gradual opening and closingvalve, illustrated in FIGS. 22.1, 22.2, 22.3, where the drawingsindicate the valve positions totally open (22.1), partially open (22.2)and totally closed (22.3). For using the innovative actuator cylinderconcept in smart completion valves, it was necessary to divide thesystem into 2 or 4 smaller actuator cylinders positioned laterally tothe axis of the production column so that the actuation of these,closing or restricting a zone flow, did not affect the production of theothers. It is highlighted that, in a smart completion, the objective isto produce or inject in several zones together with independent controlfor each interval. Each interval will produce or inject through itsrespective valve, the flow of which will flow or enter laterally fromthe annular space into the column where it will mix with the productionof the other zones. The amount of teeth in the rack will determine thesize of the opening in the actuator cylinder per pressure xdepressurization cycle. In this way, it is understood that the openingand closing process is not continuous, but stepped, although such stepscan be formed by small increments.

It is a eleventh object of the present invention to provide a selectingvalve of operation fluid comprising a selecting valve body (65) providedwith two passages in order to segregate the flow of one primary fluid ofthe flow of one secondary fluid, being the primary fluid provided withat least a property different from the secondary fluid.

It is a twelfth object of the present invention to provide the use ofselecting valve for controlling operation and maintenance of gas liftequipment where the selecting valve is as defined in this descriptionand is intended to an exploration system of drilled well.

Oil reservoirs need, at some point in their productive lives, a methodto supplement the energy (pressure) of hydrocarbon bearing rocks. Thepreferred artificial lifting methods in the underwater completionsand/or high discharge wells are: gas lift and/or BCS.

Gas lift mandrels are devices with a side pocket, eccentric relative tothe center of the production column, where valves will be housed whichwill allow one-way flow of the annular space (space between the coatingand the production column) into the production column. Typically, thesemandrels, with their respective valves, are positioned as deeply aspossible inside the wells. These valves allow the gas passage beinginjected into the annular space to gasify the produced fluids, reducingthe density of the mixture and allowing the pressure energy of thereservoir rocks to be enough to cause the flow to reach the productionfacilities. The mandrel itself has only holes that, without itsrespective valve housed in the pocket, would pass in both directions“column×annular”. However, with the valve installed, this path is onlyin the “annular×column” direction.

Because it is a point of communication between the annular and theproduction column, it is there that the circulation of completion fluidsoccurs when it is necessary to remove the oil from the columns and todamp the wells. When there is circulation without a probe being on thewell, this may mean that the gas-lift valve is housed in the pocket ofits respective mandrel and in this case the flows of circulated fluidsshould be greatly reduced so as not to damage these valves. During aworkover, if this valve can be removed with slickline, it will bepossible to increase the flow rate sufficiently, and almost withoutrestrictions, for an efficient cleaning of the column.

It should be noted that the damage caused in a gas lift valve has thepotential to result in probe workover (resulting in significantproduction costs). Mainly, if the damage is in the “check valve” (valvethat allows one way flow “annular x column”) of the valve. In this case,the produced fluids fill the annular space and the column is no longer asafety barrier.

The device, hereinafter referred to as the selective valve, proposes tobe an advantageous alternative to the current gas lift mandrels,allowing liquid and gas flows at the maximum possible flow rates,reducing probe times and providing more effective column cleaning duringworkovers. This device is specially designed to be positioned below BCSassemblies and can be used at any point in the production column.

When the proposed device is used together with BCS (SubmersibleCentrifugal Pumps) and positioned below them, it is even possible tochange the conventional gas lift mandrel (when removing the “motor-pump”assemblies) without needing to remove the selective valve.

The gas lift valve applied in the selective valve of the presentinvention is provided with two passages being them one primary hole (19)and one secondary hole (20), in order to segregate the flow of oneprimary fluid of the flow of one secondary fluid, being the primaryfluid provided with at least a property different from the secondaryfluid, additionally the valve is composed of the following items:

-   -   valve body (65);    -   sealing piston (66) comprising at least one primary actuation        mechanism (67);    -   primary hole (19);    -   flow tube (68) comprising at least one secondary actuation mean        (69); and    -   secondary hole (20);

wherein:

-   -   primary (19) and secondary (20) holes transversally arranged in        the valve body (65);    -   the sealing piston (66) and the flow tube (68) longitudinally        arranged inside the valve body (65);    -   the sealing piston (66) aligned with the flow tube (68) and        arranged in the lower end (71) thereof.

The distinction property of one primary fluid from one secondary fluidis selected from: compressibility, viscosity, density, pressure or acombination thereof. Being preferably the gas lift valve applied in theselective valve (SV) of the present invention positioned below the setof submerged centrifugal pumps (BCS), and the lower end of the flow tube(71) geometrically compatible with the sealing piston head (66).

Regarding the primary actuation mechanism (67) and secondary actuationmechanism (69), preferably such actuation means are each one a spring,but not limited to it. However, the secondary actuation mechanism (69)spring comprises elastic constant higher than elastic constant of theprimary actuation mechanism spring (67).

The selective mandrel is composed of the following items:

-   -   Tube with perforation (73);    -   Selective valve, as defined above;    -   Centralizer with upper elastomer;    -   Conventional gas-lift mandrel (21); and    -   Centralizer with lower elastomer.

It is a thirteenth object of the present invention to provide anelectro-hydraulic (EP) connector for exploration system of drilled wellcomprising:

a. at least one internal assembly (22); and

b. at least one external assembly (23)

wherein:

-   -   the internal assembly (22) is able to couple to the external        assembly (23);    -   the internal assembly (22) has electrical connections (87 and        80) and hydraulic connections (76);    -   the external assembly has electrical connections (87 and 80) and        hydraulic connections (76); and    -   the connections are allocated in order to coincide when the        coupling occurs.

It is a fourteenth object of the present invention to provide anelectric-hydraulic expansion joint comprising:

a. tubular lower component provided with:

-   -   thread in the lower part for connecting into electro-hydraulic        connector;    -   sealing in the upper part between the lower component and the        inner cylinder;    -   hexagonal lock system able to prevent the internal column turn        and to allow the torque transmission between lower and upper        component;    -   lock system for column decline with the extension fixed in the        totally closed position;    -   external ring (upper and lower) of external hydraulic and        electric lines alignment;    -   bars for filling the empty space between external hydraulic and        electric lines; and    -   protection liner of internal hydraulic and electric lines,

b. tubular upper component provided with:

-   -   cylindrical top (95) with thread in the center for inner sliding        tube;    -   thread for connection into the production column (96); and    -   peripheral threads (97) for connecting hydraulic and electric        lines.

It is a fifteenth and last object of the present invention is to providean exploration method in drilled well using an electro-hydraulicconnector and/or electric-hydraulic joint as defined in thisdescription.

In one embodiment, electric connectors (80, 87) have protectionmechanism (78, 85).

In one embodiment, protection mechanisms (78, 85) are driven by mechanicelastic device (79, 86).

In one embodiment, hydraulic connectors have sealing (89) in order toensure complete water-tightness thereof.

The present invention has also the following advantages: enable the useof smart completions of multiple zones; reduce welding times inworkovers for exchanging sets of joint BCS with smart completion; andallow completions with hydraulic valves remotely controlled.

For purposes of the present invention, the term “annular region”consists of the region of clearance between the inner wall of theremovable capsule and the elevation assembly or the pumping duct, asmounting arrangement. The annular region generally comprises the regionbetween the main duct, whereby the well produces fluids, and the coatingof the said well.

All objects of the present invention, in one embodiment, are intendedfor the exploration of drilled wells for extraction/elevation ofhydrocarbons, of which may be listed: petroleum; gas; bitumen; or anyother equivalent, of commercial interest for processing and/orapplication in several areas of the industry.

EXAMPLE 1 Preferred embodiment

The examples here shown aim to exemplify only one of the several mannerto perform the invention, however not limiting the scope thereof.

According to FIG. 1, there is one first main tube (MT1) having packerseal bore (11) in its lower portion. Inside the said first main tube(MT1) it is associated a first inner capsule (IT1) provided with gaslift mandrel (21), isolating valve (28) and primary coupling (29). Thefirst inner capsule (IT1) also has an upper polished region (15A) forseating the packer feedthru (3).

Internally associated to the first inner capsule (IT1), it is seen thefirst lifting assembly (PA1) provided with flapper valve (2), fixationclamp (5), packer feedthru (3), pumping device (4), pressure sensor PDG(8), injection valve (30) and secondary coupling (12). When insertedinto the first main tube (MT1), the primary coupling (29) present in thefirst inner capsule (IT1) is coupled into the packer seal bore (11) andseals fluids leakage through an elastomeric sealing (31) present in thesaid primary coupling (29).

When associating the first lifting assembly (PA1) to the first innercapsule (IT1), the secondary coupling (12) is responsible for openingthe isolating valve (28) present in the first inner capsule (IT1).

FIGS. 4.1 and 4.2 illustrate a sequence of removal of the first liftingassembly (PA1) for wells of a single producing zone (7). FIG. 4.1illustrates the first lifting assembly (PA1) inserted into the firstinner capsule (IT1) that, in turn, is inserted into the first main tube(MT1). In this position, the primary coupling (29) present in the firstinner capsule (IT1) is inserted into the packer seal bore (11) presentin the first main tube (MT1). In turn, secondary coupling (12) isinserted into the isolating valve (28), in order to keep it opened,allowing fluids production from the drilled well.

FIG. 5 illustrates the complete mount of the lower part of a productioncolumn (1) for well with more than one producing zone (7), the knowncompletions of multiple producing zones. It is noted the presence offlapper valve (2) preventing fluids return downstream thereof, fixationclamp (5), and packer feedthru (3) responsible for sealing and seatingthe second lifting assembly (PA2) inside the second inner capsule (IT).The pumping device (4) is located below the packer feedthru (3). Thelocator feedthru (6) are responsible for isolating several producingzones that may be met by the present invention. In image 5, the upperlocator feedthru (6A) separates the first producing zone (7A) from theupper region, where the pumping device (4) is located. A pressure sensorPDG (8) and a smart valve (9) are previewed to imply in the welloperation, according to external commands, or pre-scheduled. Lower down,its is found the lower locator feedthru (6B) segregating a secondproducing zone (7B) and, then as in the first producing zone (7A), thesaid second producing zone (7B) has pressure sensor PDG (8) and smartvalve (9), besides a handling tool (10). Still in image 5, there is thepacker seal bore (11) responsible for housing the secondary coupling(12). Finally, it is seen in the FIG. 5, inner valves (13) present inthe first producing zone (7A) and in the second producing zone (7B),such that to allow the produced fluids in the said zones to permeate theinner part of the column through screwed holes (14), also present inboth producing zones (7A and 7B). Inner valves (13) will be detailedalong the description. In this image, it is shown how to apply theknowledge of using a capsule to have the submerged centrifugal pumpingassembly in completions of multiple producing zones.

FIGS. 6A and 6B detail mechanisms inside the production column (1) formultiple producing zones, in order to promote a better view thereof.Thus, FIG. 6A details the flapper valve (2) preventing the return of theproduced fluids and those already pumped downstream thereof, thefixation clamp (5) fixing electric cables and hydraulic lines, amongothers, the packer feedthru (3) centralizing and fixing the secondlifting assembly (PA2) inside the second inner capsule (IT2) and thepumping device (4) supplying energy to the fluid that is being producedfrom the drilled well, in order to pump it and remove it, being the saidpumping device (4) located below the packer feedthru (3). FIG. 6Bdetails the upper locator feedthru (6A) separating the first producingzone (7A), where it is also noted a pressure sensor PDG (8) and a smartvalve (9) arranged for implying in the well operation, according toexternal commands, or pre-scheduled. Below it is noted the lower locatorfeedthru (6B) segregating a second producing zone (7B) also withpressure sensor PDG (8) and smart valve (9).

Also in FIG. 6B, it is clear the view of the handling tool (10)responsible for opening inner valves (13) present in the first producingzone (7A), and in the second producing zone (7B), in order to allow theproduced fluids in the said zones to permeate the column inner partthrough screwed holes (14), also present in both producing zones (7A and7B). In this image, it is clear that inner valves (13) are open andscrewed holes (14) allow fluids entering until the second liftingassembly (PA2). Finally, it is noted the packer seal bore (11) havingthe secondary coupling (12).

FIG. 7 illustrates the second lifting assembly (PA2), which may beeasily removed from inside the second inner capsule (IT2), in order toallow the pumping device (4) exchange without the need of onerousworkovers. FIG. 8 discloses the second inner capsule (IT2) with upperpolished region (15A) for seating the packer feedthru (3), besides theinner valves (13) allowing the produced fluids passage through screwedholes (14). The lower polished regions (15B) are useful for correctseating of the upper and lower locator feddtrhu (6A and 6B). Thesecondary coupling (12) ends the second inner capsule (IT2). The saidsecond inner capsule (IT2) is a tube aiming to have the second liftingassembly (PA2), in order to avoid possible parts to loose from the saidsecond lifting assembly (PA2) when removing this. When having the partsthat possibly come to detach from the second lifting assembly (PA2), thesecond inner capsule (IT2) avoids the parts to go to the bottom of thewell and generate onerous and complex fisheries. The second innercapsule (IT2) may be easily removed, clean and replaced in the secondmain tube (MT3). Finally, image 9 illustrates the second main tube(MT2), which is the coating tube of the production column (1). The saidsecond main tube (MT2) is responsible for having screwed holes (14),allowing the produced fluids to pass to the inner part of the productioncolumn. Also about the second main tube (MT2), the same has packer sealbore (11) in its lower part so the well may be closed when it is notwith the second inner capsule (IT2) dully positioned.

FIGS. 10.1, 10.2 and 10.3, illustrate how inner valves (13) are operatedby the handling tool (10). FIGS. 10.1, 10.2 and 10.3 were arranged witha representation in plant (arranged in the lower part of the in liftingviews) of the inner part of the handling tool (10) and of the innervalve (13), in each one of the situations depicted. The vector (16)indicates the handling tool (10) displacement that, according to FIG.10.1, is in a position where the handling tool (10E) splines areconflicting with the inner valve (13E) splines, being then, the movement(vector 16) imposed by the handling tool (10) is transferred to theinner valve (13), that also starts to displace in the vector direction(16). FIG. 10.2 depicts this movement in one intermediate instant, alsowith handling tool (10E) splines displaced from inner valve (13E)splines. Finally, image 10.3 depicts one instant that, through thehandling tool (10) turn, the handling tool splines (10E) are alignedwith the inner valve (13E) splines, such that the said handling tool(10) keeps its movement in the vector direction (16), however the innervalve (13), provided with the inner valve splines (13E), keeps stopped.Also, in image 10.3, it is realized that screwed holes (14) were opened,allowing the fluids to enter from the producing upper zone (7).

FIG. 11 illustrates the pumping device (4), with one electric engine(4A) coupled to a submerged centrifugal pump (4B). This set is known bythose skilled in the art as set of BCS, or set of submerged centrifugalpump.

According to FIG. 12, the electro-hydraulic telescopic joint (TJ) of thepresent invention is composed of: outer liner (32), upper concentricsleeve (33), outer flow tube (34), cables (35), expandable hydraulicunit (36), sliding sleeve (37), inner liner (38), inner flow tube (39),lower concentric sleeve (40) and driving line (41) for driving themechanical lock (42).

The mounting of the electro-hydraulic telescopic joint (TJ) is made byassociating between outer liner (32) and inner liner (38). The upperconcentric sleeve (33) has one central hole for associating the outerflow tube (34) and several concentric smaller holes where expandablehydraulic units (36) are associated. Through the upper annular space(32A), in communication with the lower annular space (38A) hydraulicflow is passed for driving valves and chemicals for chemical injectionmandrels. Expandable hydraulic units (36) are coupled one in another, inorder to achieve, when totally open, a length greater than the totalcourse of the electro-hydraulic telescopic joint (TJ) totally open. Thismakes necessary to avoid efforts transfer being for these units and forouter liners (32) and inner liners (38). The cable (35) is mounted inspiral way around the inner flow tube (39). Along the outer flow tube(34) the cable (35) is attached, kept slightly pulled by the slidingsleeve (37). The said sliding sleeve (37), when traveling the inner flowtube (39) length, through contraction, or expansion of theelectro-hydraulic telescopic joint (TJ), causes the cable (35) spirallyarranged around the inner flow tube (39) to be compacted, or extended,without damaging the said cable (35).

The set composing the named outer liner (32) is formed basically by theexpandable hydraulic units (36), outer flow tube (34) and upperconcentric sleeve (33). The said outer liner (32) is associated to theinner liner (38) by coupling the outer flow tube (34) to the inner flowtube (39) through the sliding sleeve (37). Once associated to the outerflow tube (34), the sliding sleeve (37) slides around the inner flowtube (39), promoting the expansion and contraction of theelectro-hydraulic telescopic joint (TJ). Optionally, it is possible toadd to the electro-hydraulic telescopic joint (TJ) a mechanical lock(42) that, through the driving line (41), allows the relative movementbetween the sliding sleeve (37) and the inner flow tube (39). In asummarized manner, it is highlighted that the mechanical lock (42) isused to lock or not the electro-hydraulic telescopic joint (TJ).

FIGS. 13 and 14 illustrate one comparison of drilled wells havingproduction columns (1) and telescopic joint (TJ). Specifically, FIG. 13illustrates one well wherein the production column is not equipped withtelescopic joint (TJ), and FIG. 14 illustrates a production column (1)provided with the said telescopic joint (TJ). An example of comparisonof the application for “Electro-Hydraulic Telescopic Joint (JTEH)” maybe seen and compared in FIGS. 13 and 14.

In FIG. 13, without the electro-hydraulic telescopic joint (TJ), a wholelifting assembly (PA) is engaged in two points, which are packerfeedthru (3). As these elements normally are unfixed from the productioncoatings by applying traction, two of these elements duplicate necessaryefforts for “unseating” of these devices, what is not normally achievedby overcoming the capabilities of the production tubes. Thus, specialoperations significantly would be necessary to separate the liftingassembly part (PA) from the production column (1) remaining.

In FIG. 14, the electro-hydraulic telescopic joint (TJ) allows thelifting assembly (PA) to be emerged in the surface without thecompletion remaining is removed.

FIG. 15 discloses an embodiment of the shut-off valve (CV), where it ispossible to note the linear actuator (43), responsible for opening andclosing of the production column and, inversely, of the annular space(AE). Together with linear actuator (43) there is a rack (44) arrangedin contact with a gear (45) that, when displaced, provokes the shut-offvalve body (46) turn.

Also in FIG. 15, it is possible to note the presence of a spiralreservoir (53) connected to the linear actuator (43), the said spiralreservoir (53) is detailed further on.

Gears (45) are constructed with the ratchet system (47), such that theshut-off valve body (46) rotates only in one direction.

FIG. 16 illustrates a cross side view of the system of gear (45) andrack (44), where it is possible to note the arrangement of the ratchetsystem (47), this system formed by return elastic elements (48) pressingprojections at angle (49) against the gear inner part (45). The saidgear inner part (45) has cavities (50) for accommodating projections atangle (49). In this image, the linear actuator (43) and rack (44)operation is apparent. Also in FIG. 16, it is possible to note the upperconnection flange (51) and the lower connection flange (52), bothresponsible for associating the shut-off valve (CV) wherever it isnecessary.

Image 17 highlights the linear actuator (43) operation associated to therack (44) operating the ratchet system (47) formed by the gear (45)having cavities (50), return elastic elements (48) and projections atangle (49).

In image 18, an exploded view depicts the shut-off valve (CV)components. When moving the linear actuators (43), associated to racks(44), in the ascending or descending direction, will result in the gearrotation (45) in the clockwise or counter-clockwise direction. In caseof descending movement by linear actuators (43), projections at angle(49), forced by the return elastic elements (48) against the cavities(50) present in the gears (45), will force the grooved cylindrical shaft(46S) rotation, being the said grooved cylindrical shaft (46S) joint tothe shut-off valve body (46), the latter rotates, causing to open orclose of the drilled well and, in , causing to open or close the annularspace (AE). On the other hand, when actuated by the racks (44) inascending direction, gears (45) rotate in the counter-clockwisedirection without transmitting the rotation for grooved cylindricalshaft (46S) due to the fact that the projections at angle (49) andreturn elastic elements (48) are compressed inside the cavities (50) ofthe grooved cylindrical shaft (46S), allowing the free rotation of thegears wheels (45). That is, only during descending movements of thelinear actuator (43) it is allowed to transmit the rotation for shut-offvalve body (46) and, thus, drive the shut-off valve (CV) opening andclosing.

During rises, by depressurizing the well annular space (AE), the spiralreservoir (53), operating as spring, withdraws the linear actuators (43)back to above not allowing the shut-off valve body (46) to move. Thisfact is important, since it is not necessary to keep the annular space(AE) pressurized all the time to allow the valve maintenance in acertain position. Therefore, a complete cycle of pressurization anddepressurization is necessary to establish a certain position in thevalve. It is highlighted that this device allows its opening variation.With that, it is possible to operate it out of the open and closedpositions, only.

Also in FIG. 18, it is possible to note a cylindrical wrap (54),associated to the upper connection flange (51) and to the lowerconnection flange (52), in order to have all the set forming theshut-off valve (CV), ending the mount. The said shut-off valve (CV)mount is simple due to the tiny amount of components. The lowerconnection flange (52) mounting is started. This component will beleaked axially by one greater hole (57), where produced fluids will passand, concentrically, by one or more smaller flange holes (55) where thefluid of completion will pass resulting from the annular space (AE)during reverse circulation operations. Such flange holes (55) will beprovided from retention valves to allow the flow in single direction ofthe annular space (AE) to the column. Over the lower connection flange(52), the valve shell (56) is mounted. The valve shell (56) has shellholes (57) that, in the valve shell (56) mounting over the lowerconnection flange (52), they must be aligned with the flange holes (55).Finally, the shut-off valve body (46) is inserted into the valve shell(56), forming the main mechanism of the shut-off valve (CV).

The seating system between the parts was implemented in the metal×metalmodality, without limiting to them. It is highlighted that the shut-offvalve body (46) shall also have side holes perpendicular regarding thecentral hole, where the produced fluids of the drilled well passthrough, but without coinciding in order to allow reverse circulationswith the production hole closed, preventing the well to absorb fluids.The spiral reservoir (53) is mounted with linear actuators (43) andupper connection flange (51), over the cylindrical wrap (54).

Image 19 depicts ratchet system components (47), which are responsiblefor causing the shut-off valve body (46) rotation in a single direction.In this image, it is possible to note the grooved cylindrical shaft(46S), the gear (45), the set of projections at angle (49) and returnelastic elements (48) and, finally, the ratchet system mounting (47).

Image 20 illustrates, in plant, the main mechanisms of the shut-offvalve (CV). It is possible to note the presence of cylindrical wrap (54)having the valve shell (56), the shut-off valve body (46), the linearactuators (43) and gears (45).

FIGS. 21.1, 21.2, 21.3 and 22 disclose an embodiment for a system forcontrolling valve (6) associated to shut-off valve (CV), such that toprovide control thereof.

FIG. 21.1 refers to shut-off valve (CV) during a flow being producedfrom the drilled well. FIG. 21.2 illustrates the shut-off valve (CV)during a production stop and, finally, image 21.3 illustrates theshut-off valve (CV) in the well reopening wherein it becomes necessaryto pressurize the annular space.

In FIG. 21.1, the control mechanism (CM) is not driven by the innersleeve (17), since there is a flow being produced and, therefore,keeping the said inner sleeve (17) in an upper position. In thisposition, the mechanic actuator (58) is extended and the drainage hole(60) does not allow the fluid to pass through the primary duct (63).Such primary duct (63), connects the production main hole to the linearactuator (43), such that the fluid pressure, which is being produced, isthe same acting over the linear actuator (43). In this position, thedifferential piston (61) does not allow the pressure of the annularspace (AE) to be detected by the hydraulic actuator (59), such that thepressure performed over the said hydraulic actuator (59) is the pressureresulting from the primary duct (63), which is in the same pressure ofthe fluids being produced from the drilled well. It is also previewed ananti-return valve, or one way valve (V) arranged in the communicationbetween the annular space (AE) and the shut-off valve (CV) internalpart.

According to image 21.2, when the flow is stopped, the first actuationmean (18) displaces the inner sleeve (17) against the mechanic actuator(58), such that this allows the fluid, being produced, pressure to passtowards the hydraulic actuator (59), displacing it to the left. Providedwith drainage hole (60), the hydraulic actuator (59) connects the upperand lower portions of the primary duct (63), such that linear actuator(43) is displaced in the ascending direction. In this position, thedifferential piston (61) is found in the arrangement presented in FIG.21.1, since the annular space (AE) was not pressurized, necessarypre-requirement so the said differential piston (61) is displaced. Alsoin this image, it can highlight that the secondary elastic element (60),associated to the mechanic actuator (58) is compressed.

FIG. 21.3 illustrates one instant wherein the annular space (AE) waspressurized and displaced the differential piston (61) to the right,what opened the passage for the annular space fluid to fill a secondaryduct (64), being the said secondary duct (64) communicating with theleft side of the hydraulic actuator (59), such that the said hydraulicactuator (59), under the annular space (AE) pressure displaced to theright, so the drainage hole (60) cuts the communication between theupper and lower part of the primary duct (63). This causes the pressureof the annular space (AE), directly connected to the linear actuator(43), to displace the said linear actuator (43), forcing the ratchetsystem (47) rotation, opening the shut-off valve (CV). Accordingly, thepressure actuation of the annular space (AE) over the said linearactuator (43) was clear.

The amount of teeth in the rack (44) will determine the opening size inthe shut-off valve body (46) by cycle of pressure x depressurization.Thus, it is understood that the opening and closing process is notcontinuous, but stepped, also such stepping may be formed by smallincrements.

FIG. 22.1 illustrates the shut-off valve (CV) with shut-off valve body(46) controlling only the communication between the annular space (AE)and the duct inside the valve conducting the produced fluids from thedrilled well, according to the present invention teachings. Morespecifically, FIG. 22.1 discloses a second embodiment of the shut-offvalve (CV) in a position allowing the communication between the annularspace (AE) and the duct inside the valve.

FIG. 22.2 illustrates one instant wherein, by acting the control fluidsin the linear actuator (43), the rack (44) is displaced, inducing thegear (45) to rotate, causing the shut-off valve body (46) to assume anintermediate position.

FIG. 22.3 illustrates one instant where the shut-off valve body (46) isin the blocking position of the connection between annular space (AE)and the production column internal part. By acting the linear actuator(43), the rack (44) displaced the gear (45) that induced the shut-offvalve body (46) to rotate. It is important to highlight that shut-offvalve (CV) was described using a linear actuator (43) for displacing itsmoving parts, so those skilled in the art will value this knowledge andwill know to apply other rotating options as the hydraulic engines,electric engines, among other examples.

Continuing with the completion system now proposed, FIG. 23 shows anembodiment of the selective valve (SV) of the present invention, havingits elements indicated: selecting valve body (65), sealing piston (66)comprising primary actuation mechanism (67), primary hole (19), flowtube (68) comprising secondary actuation mechanism (69), lower end (71)and upper end (72), secondary hole (20) and, finally, the fluid entry(70).

During the gas injection operations in the annular space of thecompletion housed in the drilled well for performing the gas-liftelevation, the said gas will enter into the selective valve (SV) throughthe fluid entry (70) and the “upstream×downstream” pressuredifferentials will reach the force of the primary actuation mean (67),causing the sealing piston (2) to lower and the gas to pass inside theproduction column that fits this completion through primary hole (19),but the viscosity of this first gas will not be able to generate enoughfriction in the flow tube (68) walls enough to reach the secondaryactuation mean (69) force. The gas injected in the annular and directedby the selective valve (SV) to the primary hole (19), will enter intothe gas-lift mandrel (21) and will gasify the production column,reducing the density of the produced mixture, as currently happens. Itis necessary to highlight that the gas, as soon as enter into theproduction column, remains inside the space formed between upper locatorfeedthru (6A) and lower locator feedthru (6B), promoting the propersealing of the completion fluid, such that the said fluid can enter onlyinto the gas-lift mandrel (21), reducing the density of the producedfluid.

FIG. 24 depicts an embodiment if the completion fluid is liquid, wherethe Hydrodynamic friction caused in the flow tube (68) walls will be bigenough to generate a hydrodynamic drag of the said flow tube (68)downwards, such that this reaches the force of the secondary actuationmean (69) and compressing the “sealing piston” (66) against the upperand lower faces thereof. This promotes the two-way sealing. At thispoint, the opening present in the upper end (72) will coincide to thesecondary hole (20) and the fluid will enter into the production columnthrough the said secondary hole (20).

FIG. 25 illustrates the selective valve (SV) of the present inventionassembled in a completion for wells, where it is possible to note thepaths the completion fluid can take after the selective valve (SV). Whendiverting the path inside the gas-lift mandrel (21) and enter by theperforation (73) arranged in the lifting main tube of the completion,the completion fluid does not pass inside the gas-lift mandrel (21), ina way to preserve it, once gas-lift mandrels (21) do not support higherviscosities fluids (water, oil, chemicals, etc.). Other reason for usingthe selective valve (SV) is the fact of allowing flow rates of pumpedliquids to be big enough to promote effective cleaning of the productioncolumn, preserving the integrity of the gas-lift mandrels (21) installedin the production column of the completion now proposed by the presentinvention.

Figures from 26 to 28 disclose an electro-hydraulic (EP) connector forcompletion of drilled wells, where electro-hydraulic connectors (EP)allow the disconnection of the production column (1) part formaintenance, according to the present invention teachings.

According to FIG. 26A, there is the external assembly (23) of theelectro-hydraulic (EP) connector where it is possible to view the systemof stamps (83) that are responsible for displacing the lower electricalcontacts protector (78) by compressing the lower spring (79). The uppersurface (84) is responsible for displacing the upper electrical contactsprotector (85) by compressing the upper spring (86). In this figure, theupper spring (86) is extended and the upper electrical contactsprotector (85) is positioned in order to provide the correct protectionto outer electric connectors (87). The electrical connection system alsooccurs in a modular form, it is enough to add more electrical connectionassemblies.

In the FIG. 26B, it is possible to view the internal assembly (22) ofthe electro-hydraulic (EP) connector in half cut. The threaded element(74) is responsible for interconnecting the internal assembly (22) ofthe electro-hydraulic (EP) connector to the production column remaining.The polished region of the connector (75) is responsible for ensuringthe water-tightness of a hydraulic connection (76) operating from oneelastomeric elements assembly for connector (77) (these elements arepresent in the external assembly (23) of the electro-hydraulic (EP)connector) ensuring the complete sealing of the said hydraulicconnection (76). The several hydraulic connections (76) occur in modularform, being possible to increase the number of connecting points, orreduce them. When the electro-hydraulic (EP) connector is decoupled thelower electrical contacts protector (78) are in the extended positionthrough the force action performed by the lower spring (79) in order toensure proper protection of the internal electric connectors (80). Theinternal tubular region (81) is responsible for supporting wellpressures and mechanical stresses of the production column. Between thepolished region of the connector (75) and the internal tubular region(81) the region located for allocating hydraulic and electric lines (82)such that the said lines do not experience obstacles occurring insidethe internal tubular region (81).

According to FIG. 27, it can be seen the electro-hydraulic (EP)connector components when it is in the “connected” position. In thisview, the internal assembly (22) is dully coupled to the externalassembly (23) and internal electric connectors (80) and externalelectric connectors (87) are coupled, besides the hydraulic connection(76) that is also dully connected. It is possible to note that upper(86) and lower (79) springs are compressed, internal and externalelectric connectors (80 and 87) are aligned and dully connected and alsohydraulic connectors (76) are dully positioned in the polished region(75) in order to ensure total water-tightness of the hydraulic lines.

FIGS. 28.1 and 28.2 depict a sequence of removal of pumping device (4)by disconnecting the electro-hydraulic (EP) connector, according to thepresent invention.

In FIG. 28.1 it can be noted the accessories of a lower completion (88),generically represented. In this illustration, the pumping device (4),generally formed by the engine and pump assembly are represented in amerely illustrative manner and they are connected to the lowercompletion (88) remainder through electro-hydraulic (EP) connector ofthe present invention.

FIG. 28.2, as FIG. 28.1, illustrates a smart completion provided withelectro-hydraulic (EP) connector, with the difference of being in thedisconnected position. In this figure, it is easy to view how thepresent invention will facilitate the decoupling between the upper parthaving the pumping device (4) and lower completion (88), for maintenanceof the said pumping device (4), formed by a BCS, for example. It isnoticeable that the external assembly (23) of the electro-hydraulic (EP)connector is associated to the upper part that was removed from thesmart completion and the internal assembly (22) is associated to lowercompletion (88) of the said smart completion.

FIG. 29 discloses a second embodiment for electro-hydraulic telescopicjoint (TJ) of the present invention. As illustrated, this tool iscomposed of the following elements:

Tubular lower component with the following characteristics: outer thread(27) for connecting into electro-hydraulic (EP) connector, sealing (89)in the upper part between the outer tube (24) and the inner tube (25),hexagonal lock system (26) to avoid the inner column to rotate in false,performing torque transmission between the lower and upper component,secondary lock system (90) for column decline with the extension fixedtotally in the closed position, external ring upper (91) and externalring lower (92) for aligning external hydraulic and electric lines,filling bars (93) of empty space between the external hydraulic andelectric lines and, protection liner (94) of the internal hydraulic andelectric lines.

Tubular upper component with the following characteristics: cylindricaltop (95) with thread in the center to the inner tube (25); thread forconnecting into the production column (96) and peripheral threads (97)for connecting hydraulic and electric lines.

The components comprise the electro-hydraulic telescopic joint (TJ) ofthe FIG. 29 are dully described below.

The inner tube (25) refers to a conventional expansion joint. The innertube (25) is composed of one conventional polished cylinder slidingupwards and downwards, with sealing in the outer liner top. The definedsliding course for balance will depend on the constructivecharacteristics, but it can reach up to 6 meters.

The hexagonal lock (26) in the lower end of the inner cylinder (25)avoids the independent rotation, impairing torque. The protection liner(94) is responsible for connecting in the lower part of the column. Thesealing (89) system with the inner cylinder (25) is located on the top.Internally, the protection liner (94) is machined with shape to keep thecylinder alone in case of rotation. The outer body is machined withgrooves to partially house the conduction hydraulic and electric lines.

The protection liner (94) refers to a cylinder coating the outer lines,mechanically protecting against impacts on the lines and keeping thelines positioned so they do not remain out of the position. Hydrauliclines are miniatures of the main expansion joint, with one outer tubeand one inner tube. The outer fixed and the inner sliding, with sealingof the outer tube top. The electric lines are similar to hydrauliclines, but with electric conduction purpose.

Those skilled in the art will appreciate the knowledge presented hereinand may reproduce the invention in the embodiments presented and inother embodiments within the scope of the attached claims.

1. A completion system for drilled wells comprising: a) valvesmechanisms; b) drives; c) sensors; d) an expandable joint for adjustingthe distance between system components; e) a shut-off valve; f) a systemof controlling the shut-off valve drive; g) a control valve of operationand maintenance; and h) a decoupling/expandable electro-hydraulicconnector.
 2. An exploration system of a drilled well comprisingelevation means of fluid in the drilled well, wherein the said elevationmeans is a set of submerged centrifugal pumps and/or a system of gaslifts, the elevation means being arranged inside a capsule (IT) housedin a removable manner inside the drilled well.
 3. An exploration systemof multiple producing zones in drilled well comprising: a) at least twoextraction regions, wherein the extraction regions are isolated fromeach other in the annular region; and b) an elevation assembly (PA)arranged inside a coating capsule (IT); wherein the annular regioncomprises a perimeter clearance existing between the elevation assembly(PA) and the inner wall of the coating capsule (IT).
 4. A method ofextraction in a drilled well with an exploration system of multipleproducing zones, wherein the system is provided with a locatorsfeed-thru (6) with a packer seal bore (11) and an elastomer for sealing.5. A capsule for conditioning components of an exploration system of adrilled well comprising a hollow inner region and a housing outer regioninside the drilled well, the capsule: a) housing elevation and controlcomponents for extracting the fluid contained in the drilled well; andb) allowing the simultaneous mounting and removal of the said elevationand control components for extracting from inside the well.
 6. Anexploration method in a drilled well with a capsule for conditioningcomponents of the exploration system comprising the following steps: a)inserting a coating capsule (IT) inside a drilled well; b) inserting anelevation assembly (PA) inside the coating capsule (IT).
 7. A telescopicjoint for adjusting a mounting distance between components of anexploration system of a drilled well comprising a linear extension meansfor connecting components of an elevation assembly (PA) and/or foradjusting the total length of the elevation assembly (PA).
 8. Anisolating valve for an exploration system of a drilled well comprising ameans for opening and closing a drive through pressure control appliedin an annular space (AE) of the valve.
 9. (canceled)
 10. (canceled) 11.(canceled)
 12. (canceled)
 13. An electro-hydraulic connector for anexploration system of a drilled well comprising: a) at least oneinternal assembly (22); and b) at least one external assembly (23)wherein: the internal assembly (22) is able to be coupled to externalassembly (23); the internal assembly (22) has electrical connections (87and 80) and hydraulic connections (76); the external assembly haselectrical connections (87 and 80) and hydraulic connections (76); andthe hydraulic connections are allocated in a way they coincide when thecoupling takes place.
 14. An electro-hydraulic expansion jointcomprising: a) a lower tubular component provided with: a thread in alower part for connecting into an electro-hydraulic connector; a sealingin an upper part between the lower tubular component and an innercylinder; a hexagonal lock system for preventing an internal column fromturning and for allowing torque transmission between the lower tubularcomponent and an upper tubular component; a lock system for columndecline with an extension fixed in a totally closed position; anexternal ring (upper and lower) for aligning external hydraulic andelectric lines; bars for filling an empty space between the externalhydraulic and electric lines; and a protection liner for internalhydraulic and electric lines, b) the upper tubular component providedwith: a cylindrical top (95) with a thread in the center for an innersliding tube; a thread for connection to a production column (96); andperipheral threads (97) for connecting hydraulic and electric lines. 15.(canceled)
 16. An exploration method in a drilled well comprising usingan electro-hydraulic connector comprising: a) at least one internalassembly (22); and b) at least one external assembly (23) wherein: theinternal assembly (22) is able to be coupled to external assembly (23);the internal assembly (22) has electrical connections (87 and 80) andhydraulic connections (76); the external assembly has electricalconnections (87 and 80) and hydraulic connections (76); and thehydraulic connections are allocated in a way they coincide when thecoupling takes place.
 17. An exploration method in a drilled wellcomprising using an electric-hydraulic joint comprising: a) a lowertubular component provided with: a thread in a lower part for connectinginto an electro-hydraulic connector; a sealing in an upper part betweenthe lower tubular component and an inner cylinder; a hexagonal locksystem for preventing an internal column from turning and for allowingtorque transmission between the lower tubular component and an uppertubular component; a lock system for column decline with an extensionfixed in a totally closed position; an external ring (upper and lower)for aligning external hydraulic and electric lines; bars for filling anempty space between the external hydraulic and electric lines; and aprotection liner for internal hydraulic and electric lines, b) the uppertubular component provided with: a cylindrical top (95) with a thread inthe center for an inner sliding tube; a thread for connection to aproduction column (96); and peripheral threads (97) for connectinghydraulic and electric lines.